US10267119B2 - Downhole well system - Google Patents

Downhole well system Download PDF

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Publication number
US10267119B2
US10267119B2 US15/322,876 US201515322876A US10267119B2 US 10267119 B2 US10267119 B2 US 10267119B2 US 201515322876 A US201515322876 A US 201515322876A US 10267119 B2 US10267119 B2 US 10267119B2
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sensor
well system
tubular structure
fluid
downhole
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US20170159405A1 (en
Inventor
Paul Hazel
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Welltec Oilfield Solutions AG
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Welltec Oilfield Solutions AG
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Assigned to WELLTEC OILFIELD SOLUTIONS AG reassignment WELLTEC OILFIELD SOLUTIONS AG ASSIGNMENT OF ASSIGNORS INTEREST (SEE DOCUMENT FOR DETAILS). Assignors: WELLTEC A/S
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Classifications

    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B34/00—Valve arrangements for boreholes or wells
    • E21B34/06—Valve arrangements for boreholes or wells in wells
    • E21B34/08—Valve arrangements for boreholes or wells in wells responsive to flow or pressure of the fluid obtained
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B33/00—Sealing or packing boreholes or wells
    • E21B33/10—Sealing or packing boreholes or wells in the borehole
    • E21B33/12—Packers; Plugs
    • E21B33/124—Units with longitudinally-spaced plugs for isolating the intermediate space
    • E21B33/1243—Units with longitudinally-spaced plugs for isolating the intermediate space with inflatable sleeves
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B33/00—Sealing or packing boreholes or wells
    • E21B33/10—Sealing or packing boreholes or wells in the borehole
    • E21B33/12—Packers; Plugs
    • E21B33/127—Packers; Plugs with inflatable sleeve
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B33/00—Sealing or packing boreholes or wells
    • E21B33/10—Sealing or packing boreholes or wells in the borehole
    • E21B33/12—Packers; Plugs
    • E21B33/127—Packers; Plugs with inflatable sleeve
    • E21B33/1277—Packers; Plugs with inflatable sleeve characterised by the construction or fixation of the sleeve
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B34/00—Valve arrangements for boreholes or wells
    • E21B34/06—Valve arrangements for boreholes or wells in wells
    • E21B34/066—Valve arrangements for boreholes or wells in wells electrically actuated
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
    • E21B43/12—Methods or apparatus for controlling the flow of the obtained fluid to or in wells
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
    • E21B43/14—Obtaining from a multiple-zone well
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B47/00—Survey of boreholes or wells
    • E21B47/06—Measuring temperature or pressure

Definitions

  • the present invention relates to a downhole well system for producing hydrocarbon-containing fluid from a reservoir downhole. Further, the present invention relates to an inflow regulation method for adjusting the inflow of fluid in the downhole well system according to the invention.
  • the inflow of fluid is adjusted if e.g. a production zone is producing too much water or the pressure in one zone is much lower than a pressure in another zone.
  • Such adjustment is mainly performed by submerging a tool into the well, and when the tool is opposite the inflow valve to be adjusted, the tool engages the valve and opens or closes the valve.
  • Another way of adjusting the inflow is to have control lines on the outside of the metal casing, so that the valves can be adjusted from surface.
  • Adjusting the valves by submerging a tool into the well takes time, and adjusting the valves through control lines or flow lines jeopardises the well safety as the lines are to run through the main barriers at the top of the well, inducing the potential risk of a leak and thus of a blow-out. Therefore, attempts have been made to design autonomous valves, e.g. having swellable elements reacting to water or valves lowering the pressure of the fluid using a vortex principle if the water content of the fluid is too high. However, none of these autonomous valves is sufficiently reliable, as they do not always function as intended, and the adjustment of some of the valves is irreversible.
  • a downhole well system for producing hydrocarbon-containing fluid from a reservoir downhole comprising:
  • the tubular part may be a tubular metal part.
  • the well tubular structure may be a well tubular metal structure.
  • the well tubular metal structure may be arranged in the borehole, the well tubular metal structure having an outer face facing the wall of the borehole.
  • the downhole well system may be a single-cased completion comprising one well tubular metal structure.
  • the well tubular metal structure may have a substantially unrestricted inner diameter. Said inner diameter may be restricted by less than 10%.
  • the well tubular metal structure may comprise at least one production opening opposite the production zone, providing fluid communication between the annulus and the inside of the well tubular metal structure, and the inflow valve assembly may be fluidly controlling the flow of fluid through the production opening.
  • first annular barrier and the second annular barrier may be configured to be expanded to fluidly isolate the production zone.
  • the senor may be arranged outside the well tubular structure or in the well tubular structure.
  • the sensor may be a flow rate sensor, a pressure sensor, a capacitance sensor, a resistivity sensor, an acoustic sensor, a temperature sensor or a strain gauge.
  • the property may be pressure, density, capacitance, resistivity, flow rate, water content or temperature.
  • the senor may be adapted to measure the property of fluid outside the well tubular structure.
  • Outside the well tubular metal structure may be between the well tubular metal structure and a borehole in which the well tubular metal structure is arranged.
  • the senor may face the borehole.
  • the senor may be adapted to measure the property of fluid inside the well tubular structure.
  • Said sensor may be adapted to measure a pressure inside and in the annulus.
  • the sensor unit may comprise a three-port valve having a first port in fluid communication with the annulus, a second port in fluid communication with the inside of the well tubular structure, and a third port fluidly connected with the sensor so as to bring the sensor in fluid communication with either the annulus or the inside for measuring a property of a fluid in the annulus and a property of a fluid in the inside, respectively.
  • the three-port valve may be adapted to switch between a first position fluidly connecting the first port with the third port and a second position fluidly connecting the second port with the third port.
  • the sensor unit may be an insert which may be inserted in an opening in the well tubular structure adjacent the inflow valve assembly.
  • the senor may be adapted to measure a pressure inside the well tubular structure, and the system may further comprise a second sensor adapted to measure a pressure in the annulus.
  • the second sensor may be adapted to measure the pressure in the annulus outside the well tubular structure and isolated by the first and second annular barriers.
  • the senor may be adapted to measure a temperature inside the well tubular structure, and the system may further comprise a second sensor adapted to measure a temperature outside the well tubular structure.
  • the closing member may be a sliding sleeve.
  • the inflow valve assembly may comprise a valve having the closing member.
  • valve may be a throttle valve, a magnetic valve, a solenoid valve or a check valve, such as a ball check valve, disc check valve, swing check valve, or the like.
  • the senor may be arranged for measuring upstream of the passage, in the passage or downstream of the passage.
  • the inflow valve assembly may comprise several sensors.
  • Said inflow valve assembly may have one sensor arranged for measuring upstream of the passage and one sensor arranged for measuring downstream of the passage.
  • control unit may comprise a processor for comparing the measurement with a preselected property range.
  • the inflow valve assembly may comprise a plurality of passages.
  • the downhole well system as described above may further comprise a plurality of inflow valve assemblies.
  • a second sensor may be arranged in the annular space for measuring a pressure of the fluid in the annular space, the control unit being adapted to open the passage if the measured pressure in the annular space is lower than a pressure of the fluid in the production zone.
  • the sensor unit may comprise a communication module.
  • the sensor unit may comprise a Radio Frequency Identification (RFID) tag.
  • RFID Radio Frequency Identification
  • system may further comprise a downhole tool for loading data from the sensor unit.
  • the communication modules of the downhole tool and the sensor unit may communicate via an antenna, induction, electromagnetic radiation or telemetry.
  • the sensor unit may comprise an antenna.
  • the sensor unit may comprise a transducer adapted for recharging the power supply of the sensor unit.
  • the recharging may be by means of radio frequency, acoustics, electromagnetic radiation.
  • the system may further comprise a database, so that the data can be stored in the database, whereby the data can be assessed and used to follow the development of the well/reservoir in the different annulus and zones, and the data may be compared with the actual production of hydrocarbon-containing fluid from the well, so that the data can be used for optimising the production of the same well, or other wells.
  • the downhole tool may comprise a surface read-out module.
  • Said downhole tool may comprise an activation means adapted to remotely activate the sensor unit.
  • the downhole tool may comprise a driving unit, such as a downhole tractor.
  • the inflow valve assembly may comprise a storage module such as a CPU, a memory or a recording unit.
  • the power supply may be rechargeable.
  • the inflow valve assembly may comprise a turbine or propeller for providing power.
  • the inflow valve assembly may comprise a generator driven by the turbine or propeller.
  • the senor may be adapted to measure the property at predetermined intervals or continuously.
  • the downhole well system as described above may further comprise a plurality of first and second annular barriers for isolating a plurality of production zones.
  • an inflow valve assembly may be arranged opposite each production zone for adjusting the flow of fluid from the production zone.
  • the present invention also relates to an inflow regulation method for adjusting the inflow of fluid in the downhole well system as described above, comprising the steps of
  • FIG. 1 shows a cross-sectional view of a downhole well system
  • FIG. 2 shows a cross-sectional view of an inflow valve assembly
  • FIG. 3 shows a cross-sectional view of another inflow valve assembly
  • FIG. 4 shows a cross-sectional view of yet another inflow valve assembly
  • FIG. 5 shows a cross-sectional view of another downhole well system
  • FIG. 6 shows a cross-sectional view of yet another inflow valve assembly
  • FIG. 7 shows a cross-sectional view of yet another inflow valve assembly having one sensor measuring both inside and outside the well tubular structure
  • FIG. 8 shows a cross-sectional view of yet another inflow valve assembly having a sensor unit in the form of an insert
  • FIG. 9 shows a cross-sectional view of yet another inflow valve assembly having two sensors
  • FIG. 10 shows a cross-sectional view of another downhole well system.
  • FIG. 1 shows a downhole well system 1 for producing hydrocarbon-containing fluid from a reservoir 2 downhole.
  • the downhole well system 1 comprises a well tubular structure 3 having an inside 30 for conducting the well fluid to surface.
  • the downhole well system 1 comprises a first annular barrier 4 , 4 A and a second annular barrier 4 , 4 B to isolate an annulus 41 outside the well tubular structure to form a production zone 101 when the annular barriers are expanded.
  • Each annular barrier comprises a tubular part 5 adapted to be mounted as part of the well tubular structure by means of a thread 51 (shown in FIG.
  • an expandable metal sleeve 7 surrounding the tubular part and an annular space 12 between the inner sleeve face of the expandable sleeve and the tubular part.
  • the expandable metal sleeve 7 has an inner sleeve face 8 facing the tubular part and an outer sleeve face 9 facing a wall 10 of a borehole 11 , each end of the expandable sleeve being connected with the tubular part, which provides the isolating barrier when the expandable sleeve is expanded.
  • the downhole well system 1 further comprises an inflow valve assembly 14 mounted as part of the well tubular structure and arranged between the first and the second annular barriers opposite the production zone for providing fluid communication between the production zone and the inside of the well tubular structure through a passage 15 in the inflow valve assembly by adjusting a closing member 16 (shown FIG. 2 ) in relation to the passage.
  • an inflow valve assembly 14 mounted as part of the well tubular structure and arranged between the first and the second annular barriers opposite the production zone for providing fluid communication between the production zone and the inside of the well tubular structure through a passage 15 in the inflow valve assembly by adjusting a closing member 16 (shown FIG. 2 ) in relation to the passage.
  • the inflow valve assembly 14 shown in FIG. 2 comprises a sensor unit 40 having a sensor 17 adapted to measure at least one property of the fluid.
  • the sensor is powered by a power supply 18
  • the inflow valve further comprises a control unit 19 for activating the adjustment of the closing member 16 based upon the measurement of the sensor, so as to open, choke or close the passage 15 and thereby control the passage of fluid into the inside 30 of the well tubular structure 3 from the production zone 101 .
  • the sensor 17 is a flow rate sensor, a pressure sensor, a capacitance sensor, a resistivity sensor, an acoustic sensor, or a temperature sensor for measuring a fluid property such as pressure, density, capacitance, resistivity, flow rate, water content or temperature.
  • a sensor in the inflow valve assembly By having a sensor in the inflow valve assembly, the inflow valve assembly can close or choke itself without the need of control signals from surface if e.g. the production zone is producing too much water.
  • the power supply may be a small battery which may be rechargeable by inserting a tool into the well.
  • the closing member 16 is a valve slide bar 16 A slid and controlled by the control unit 19 .
  • the closing member 16 is a sliding sleeve 16 B slidable in a groove 24 in the tubular part 25 of the inflow valve assembly 14 .
  • the inflow valve assembly may comprise a valve 20 having the closing member 16 in the form of a cone 16 C, as shown in FIG. 4 , closing against a valve seat 26 .
  • the valve may be a throttle valve, a magnetic valve, a solenoid valve or a check valve, such as a ball check valve, disc check valve, swing check valve, or the like.
  • the sensor 17 may be arranged for measuring upstream of the passage 15 as shown in FIG. 2 , or arranged for measuring in the passage as shown in FIG. 3 , or arranged for measuring downstream of the passage as shown in FIG. 4 .
  • the control unit comprises a processor 21 for this purpose and for comparing the measurement with a preselected property range, so that the inflow valve assembly is adjusted if the measured property is outside the range.
  • the inflow valve assembly may comprise several sensors measuring different properties of the fluid, so that one measured property can be confirmed by another measurement. Hence if e.g.
  • the capacity measurement is capable of detecting such change, and if the temperature is also measured to drop, the increasing water content is thus confirmed.
  • the gas content increases, which can be measured by the capacitance measurement, this can be confirmed by a pressure measurement.
  • the measurements and adjustments performed by the inflow valve assembly may be stored in a storage module such as a CPU, a memory or a recording unit and a communication module 23 (as shown in FIG. 7 ) for communicating these data to e.g. a tool submerged into the well.
  • a storage module such as a CPU, a memory or a recording unit and a communication module 23 (as shown in FIG. 7 ) for communicating these data to e.g. a tool submerged into the well.
  • the inflow valve assembly 14 comprises a plurality of passages, some being open and others being closed. In this way, the volume flow of the fluid can be adjusted by opening or closing passages.
  • the downhole well system 1 comprises a plurality of inflow valve assemblies, and a second sensor 22 is arranged in the annular space 12 of the annular barriers in order to measure a pressure of the fluid in the annular space.
  • the control unit in the inflow valve assembly closest to the second sensor is adapted to open the passage if the measured pressure in the annular space is lower than a pressure of the fluid in the production zone.
  • the inflow valve assembly 14 comprises a propeller in the passage for providing power.
  • the propeller rotates a shaft 34 driving gears 35 which again drives a generator 36 transforming the rotational power into electricity for powering the sensor 17 and the control unit 19 .
  • the sensor is adapted to measure the property continuously or at predetermined intervals, e.g. once a week. Therefore, the inflow valve assembly 14 may comprise a timer 37 as shown in FIG. 6 .
  • the sensor 17 is adapted to measure both a fluid property, such as pressure, inside the well tubular structure and in the annulus 41 .
  • the sensor unit 40 comprises a three-port valve 60 having a first port 61 in fluid communication with the annulus, a second port 62 in fluid communication with the inside of the well tubular structure, and a third port 63 fluidly connected with the sensor 17 so as to bring the sensor in fluid communication with either the annulus 41 or the inside 30 in order to measure a property of a fluid in the annulus and a property of a fluid inside the well tubular structure, respectively.
  • the three-port valve is adapted to switch between a first position fluidly connecting the first port with the third port and a second position fluidly connecting the second port with the third port.
  • the sensor unit is an insert which can be inserted in an opening 64 in the well tubular structure adjacent the inflow valve assembly 14 .
  • the sensor unit 40 comprises a three-port valve 60 and fluid channels providing fluid communication between the inside of the well tubular structure and the three-port valve 60 , or fluid communication between the annulus and the three-port valve 60 depending on the position of the valve.
  • the control unit 19 controls the closing member 16 through a second control unit 19 A.
  • the sensor units of FIGS. 7 and 8 are adapted to measure a pressure inside or outside the well tubular structure.
  • the system further comprises a second sensor 17 B adapted to measure the pressure in the annulus or the pressure inside the well tubular structure, so that the sensor is capable of measuring the pressure both inside by one sensor and in the annulus/production zone by the other sensor.
  • the sensor unit may also be adapted to measure a temperature inside the well tubular structure, and the system further comprises a second sensor adapted to measure a temperature outside the well tubular structure.
  • the sensor unit comprises a Radio Frequency Identification (RFID) tag 68 .
  • RFID Radio Frequency Identification
  • the sensor unit comprises an antenna 66 for communicating with an antenna of a downhole tool 71 for loading of data from the sensor unit.
  • the communication modules of the downhole tool and the sensor unit communicate via an antenna, induction, electromagnetic radiation or telemetry.
  • the sensor unit 40 comprises a transducer 65 adapted for recharging the power supply of the sensor unit. The recharging may be by means of radio frequency, acoustics and/or electromagnetic radiation.
  • the system further comprises a database (not shown), so that the data can be stored in the database, whereby the data can be assessed and used to follow the development of the well/reservoir in the different annulus and zones, and the data can be compared with the actual production of hydrocarbon-containing fluid from the well, so that the data can be used for optimising the production of the same well, or other wells.
  • the sensor of the inflow valve assembly may measure different fluid properties of the annulus, and thus the production zone, and if these data are loaded into the database, these data along with other data from the same well or other wells can be used for a more precise prediction of the reservoir development in the future.
  • the downhole tool comprises a surface read-out module sending a first data set uphole, but only if changes are measured.
  • the downhole tool may comprise an activation means adapted to remotely activate the sensor unit through the communication module or the transducer.
  • the adjustment of inflow of fluid in the downhole well system is performed by measuring a property of the fluid by the sensor, determining if the measurement is inside or outside a preselected property range, and then activating adjustment of the closing member if the measurement is outside the range. If the measurements are within the range, new measurements are made, e.g. after a certain period of time controlled by the timer or the control unit.
  • the tubular part may be a tubular metal part
  • the well tubular structure may be a well tubular metal structure.
  • the well tubular metal structure is arranged in the borehole, and the well tubular metal structure has an outer face 6 facing the wall 10 of the borehole 41 .
  • the downhole well system is a single-cased completion, meaning that the well tubular metal structure comprises only one well tubular metal structure and therefore has no inner production casing.
  • Said well tubular metal structure has a substantially unrestricted inner diameter, meaning that the inner diameter of the well tubular metal structure is restricted by less than 10% and thus vary in the inner diameter by less than 10%.
  • the well tubular metal structure comprises at least one production opening, which is the passage 15 , opposite the production zone 101 , providing fluid communication between the annulus or borehole 41 and the inside 30 of the well tubular metal structure.
  • the inflow valve assembly is fluidly controlling the flow of fluid through the production opening 15 .
  • the first annular barrier and the second annular barrier are configured to be expanded to fluidly isolate the production zone.
  • the senor may be arranged outside the well tubular structure or in the well tubular structure. Also, the sensor may be adapted to measure the property of fluid outside the well tubular structure.
  • the sensor may face the wall of the borehole and may be adapted to measure the property of fluid inside the well tubular structure.
  • the inflow valve assembly 14 is arranged on the outer face 6 of the well tubular metal structure and between the first annular barrier and the second annular barrier opposite the production zone, providing fluid communication between the production zone and the inside of the well tubular structure through a passage 15 in the well tubular metal structure by adjusting the closing member in relation to the passage.
  • fluid or well fluid any kind of fluid that may be present in oil or gas wells downhole, such as natural gas, oil, oil mud, crude oil, water, etc.
  • gas is meant any kind of gas composition present in a well, completion, or open hole
  • oil is meant any kind of oil composition, such as crude oil, an oil-containing fluid, etc.
  • Gas, oil, and water fluids may thus all comprise other elements or substances than gas, oil, and/or water, respectively.
  • a casing, production casing or well tubular structure is meant any kind of pipe, tubing, tubular, liner, string etc. used downhole in relation to oil or natural gas production.
  • a downhole tractor can be used to push the tool all the way into position in the well.
  • the downhole tractor may have projectable arms having wheels, wherein the wheels contact the inner surface of the casing for propelling the tractor and the tool forward in the casing.
  • a downhole tractor is any kind of driving tool capable of pushing or pulling tools in a well downhole, such as a Well Tractor®.

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  • Geology (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • Engineering & Computer Science (AREA)
  • Mining & Mineral Resources (AREA)
  • Physics & Mathematics (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Fluid Mechanics (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Environmental & Geological Engineering (AREA)
  • Geophysics (AREA)
  • Measuring Volume Flow (AREA)
  • Physical Or Chemical Processes And Apparatus (AREA)
  • Measuring Fluid Pressure (AREA)
  • Indication Of The Valve Opening Or Closing Status (AREA)
  • Production Of Liquid Hydrocarbon Mixture For Refining Petroleum (AREA)
  • Feeding, Discharge, Calcimining, Fusing, And Gas-Generation Devices (AREA)
  • Devices And Processes Conducted In The Presence Of Fluids And Solid Particles (AREA)
  • Pipeline Systems (AREA)
US15/322,876 2014-06-30 2015-06-29 Downhole well system Active 2035-09-27 US10267119B2 (en)

Applications Claiming Priority (4)

Application Number Priority Date Filing Date Title
EP14174986 2014-06-30
EP14174986.1A EP2963233A1 (fr) 2014-06-30 2014-06-30 Système de fond de puits
EP14174986.1 2014-06-30
PCT/EP2015/064758 WO2016001174A1 (fr) 2014-06-30 2015-06-29 Système de puits de fond

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US20170159405A1 US20170159405A1 (en) 2017-06-08
US10267119B2 true US10267119B2 (en) 2019-04-23

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US (1) US10267119B2 (fr)
EP (2) EP2963233A1 (fr)
CN (1) CN106460483B (fr)
AU (1) AU2015282671B2 (fr)
BR (1) BR112016029578B1 (fr)
CA (1) CA2952756A1 (fr)
DK (1) DK3161247T3 (fr)
MX (1) MX2016017132A (fr)
RU (2) RU2020118299A (fr)
SA (1) SA516380502B1 (fr)
WO (1) WO2016001174A1 (fr)

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US10248141B2 (en) * 2016-05-13 2019-04-02 Cameron International Corporation Non-invasive pressure measurement system
US11753910B2 (en) * 2016-11-18 2023-09-12 Halliburton Energy Services, Inc. Variable flow resistance system for use with a subterranean well
GB2592546B (en) * 2016-11-18 2022-02-23 Halliburton Energy Services Inc Variable flow resistance system for use with a subterranean well
MY196021A (en) * 2016-11-18 2023-03-07 Halliburton Energy Services Inc Variable Flow Resistances System for use with a Subterranean Well
US11066904B2 (en) 2016-12-28 2021-07-20 Halliburton Energy Services, Inc. System, method, and device for powering electronics during completion and production of a well
CA3048917A1 (fr) 2017-03-03 2018-09-07 Halliburton Energy Services, Inc. Colonnes barrieres contenant un tensioactif viscoelastique et leurs procedes d'utilisation
CN108952680B (zh) * 2018-09-25 2024-07-02 王明显 石油产出液计量器
EP3757526B1 (fr) * 2019-06-28 2024-03-13 Hitachi Energy Ltd Agencement de capteur de réseau de résonateur
US11905800B2 (en) 2022-05-20 2024-02-20 Halliburton Energy Services, Inc. Downhole flow sensing with power harvesting
US11746627B1 (en) * 2022-05-20 2023-09-05 Halliburton Energy Services, Inc. Downhole flow sensing with power harvesting and flow control

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SA516380502B1 (ar) 2022-12-11
EP3161247A1 (fr) 2017-05-03
RU2017100408A3 (fr) 2019-02-05
RU2745370C2 (ru) 2021-03-24
RU2020118299A (ru) 2020-08-07
DK3161247T3 (da) 2021-05-25
BR112016029578B1 (pt) 2022-05-24
EP3161247B1 (fr) 2021-02-24
EP2963233A1 (fr) 2016-01-06
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CN106460483B (zh) 2020-05-29
CN106460483A (zh) 2017-02-22

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